Superhydrophobic additive

ABSTRACT

A method of treating a subterranean formation includes introducing a well cementing composition into a wellbore, the cementing composition comprising: a pumpable slurry of cement and at least one of hydrophobic material, a superhydrophobic material, and combinations; and allowing at least a portion of the cementing composition to cure. A composition includes a pumpable slurry of wellbore cement and at least one of hydrophobic material, a superhydrophobic material, and combinations thereof.

BACKGROUND

Cementing is a common well operation. For example, hydraulic cementcompositions can be used in cementing operations in which a string ofpipe, such as casing or liner, is cemented in a wellbore. The cementedstring of pipe isolates different zones of the wellbore from each otherand from the surface. Hydraulic cement compositions can be used inprimary cementing of the casing or in completion operations. Hydrauliccement compositions can also be utilized in intervention operations,such as in plugging highly permeable zones or fractures in zones thatmay be producing too much water, plugging cracks or holes in pipestrings, and the like.

In performing cementing, a hydraulic cement composition is pumped as afluid (typically in the form of suspension or slurry) into a desiredlocation in the wellbore. For example, in cementing a casing or liner,the hydraulic cement composition is pumped into the annular spacebetween the exterior surfaces of a pipe string and the borehole (thatis, the wall of the wellbore). The cement composition is allowed time toset in the annular space, thereby forming an annular sheath of hardened,substantially impermeable cement. The hardened cement supports andpositions the pipe string in the wellbore and bonds the exteriorsurfaces of the pipe string to the walls of the wellbore.

Hydraulic cement is a material that when mixed with water hardens orsets over time because of a chemical reaction with the water. Becausethis is a chemical reaction with the water, hydraulic cement is capableof setting even under water. The hydraulic cement, water, and any othercomponents are mixed to form a hydraulic cement composition in theinitial state of a slurry, which should be a fluid for a sufficient timebefore setting for pumping the composition into the wellbore and forplacement in a desired downhole location in the well.

Oil contamination in cement is one problem that may occur due to the oilin the drilling fluids and/or from the formation itself. Contaminationmay cause the formation of large oil pockets that can hinder the set ofcement. Oil contamination in cement is traditionally solved throughavoidance by adding more spacer, introducing a physical barrier and/oraltering the pump schedule in order to avoid and, when not possibleminimize overall the contamination. These approaches only address thecontinuance of oil contamination and not the oil contamination alreadypresent.

Accordingly, an ongoing need exists for a method that addresses the oilcontamination already present in the cement as well as the continuanceof oil contamination.

BRIEF DESCRIPTION OF THE DRAWINGS

The following figure is included to illustrate certain aspects of thepresent invention, and should not be viewed as exclusive embodiments.The subject matter disclosed is capable of considerable modification,alteration, and equivalents in form and function, as will occur to onehaving ordinary skill in the art and having the benefit of thisdisclosure.

FIG. 1 is a schematic representation of the silanization of a melaminesponge according to the prior art.

FIG. 2 depicts an embodiment of a system configured for delivering thecements and spacer fluids described herein to a downhole location.

FIGS. 3A,B show a functionalized sponge material and anun-functionalized sponge material in water.

FIGS. 4A,B show the distribution of superhydrophobic particles in a neatcement matrix exposed to a base oil while conditioning.

FIG. 5 shows the ultrassonic compressive strength (UCS) of two slurriescontaminated with oil-based mud (OBM), without and with funtionalizedsponge, demonstrating the effect of the functionalized sponge.

DETAILED DESCRIPTION

The present invention relates to the addition ofhydrophobic/superhydrophobic additives to cement to control oilcontamination, reducing porosity and permeability, enhancing durabilityin harsh chemical environments. The use of thehydrophobic/superhydrophobic additives may allow the cement to becontaminated by oils and oil based fluids, such as drilling muds,without compromising the structural integrity and corresponding CementBond Log (CBL). The method enables the cement to incorporate largeamounts of oil in a highly dispersed manner, reducing the formation oflarge oil pockets and unset cement areas. The incorporation of oil intothe cement in a controlled manner may provide unreactivephysical-chemical barriers that can block the corrosive effects ofchemicals within the well (i.e., CO₂, HCl, H₂S, etc.).

It has been shown that superhydrophobic sponges can be produced fromreadily available commercial sponges, such as melamine, by silanizationas illustrated in FIG. 1. Other substrate materials may be used inaddition to those made of melamine. These materials include but are notlimited to polyacryonitrile (PAN), chitin, nanocellulose andpolyurethane. In general, any electron donating site (i.e. oxygen ornitrogen in the previous example materials) to which silicon or siliconderivatives can bind may suffice.

In some embodiments, the invention is related to a method comprising:introducing a well cementing composition into a wellbore, said cementingcomposition comprising: a pumpable slurry of cement and at least one ofa hydrophobic material, a superhydrophobic material, and combinationsthereof; and allowing at least a portion of the cementing composition tocure. The at least one of hydrophobic material and superhydrophobicmaterial may comprise a polymer sponge. In some embodiments, the spongemay comprise melamine that has been functionalized by silanization.Further, the silanization may occur through the covalent bonding ofalkylsilane compounds to the secondary amine groups on the sponge. In anembodiment, the at least one of hydrophobic material andsuperhydrophobic material is present in the amount of about 0.01% toabout 25% by weight of the cementing composition. The method may furtherinclude allowing the at least one of hydrophobic material andsuperhydrophobic material to absorb oil during the setting phase of thecement composition. Additionally, the method may further include a pumpand a mixer for combining the components of the cementing compositionand introducing the composition into the wellbore.

Several embodiments of the invention are directed to a composition forwell cementing including a pumpable slurry of cement and at least one ofa hydrophobic material, a superhydrophobic material, and combinationsthereof. The at least one of hydrophobic material and superhydrophobicmaterial may comprise a polymer sponge. In some embodiments, the spongemay comprise melamine that has been functionalized by silanization.Further, the silanization may occur through the covalent bonding ofalkylsilane compounds to the secondary amine groups on the sponge. In anembodiment, the at least one of hydrophobic material andsuperhydrophobic material is present in the amount of about 0.01% toabout 25% by weight of the cementing composition.

Certain embodiments of the invention are directed to a method ofpreparing a wellbore for cementation comprising: introducing a spacerfluid into a wellbore, said spacer fluid comprising: at least one of awater based mud, an aqueous base fluid, and combinations thereof; and atleast one of a hydrophobic material, a superhydrophobic material, andcombinations thereof; and allowing the spacer fluid to absorb a portionof oil in the wellbore. The at least one of hydrophobic material andsuperhydrophobic material may comprise a polymer sponge. In someembodiments, the sponge may comprise melamine that has beenfunctionalized by silanization. Further, the silanization may occurthrough the covalent bonding of alkylsilane compounds to the secondaryamine groups on the sponge. In an embodiment, the at least one ofhydrophobic material and superhydrophobic material is present in theamount of about 0.01% to about 50% by weight of the spacer fluidcomposition. In some embodiments, at least of portion of the oil in thewellbore may be from an oil based drilling mud. The method may furthercomprise introducing comprising introducing a cementing composition into the wellbore after the spacer fluid has been introduced, wherein thecementing composition comprises a pumpable slurry of cement. Thecementing composition may comprise at least one of a hydrophobicmaterial, a superhydrophobic material, and combinations thereof. Themethod may further include allowing the at least one of hydrophobicmaterial and superhydrophobic material to absorb oil during the settingphase of the cement composition.

Aqueous Base Fluids

The cement slurry may include an aqueous base fluid from any source,provided that the fluids do not contain components that might adverselyaffect the stability and/or performance of the treatment fluids of thepresent invention. The aqueous base fluid may comprise fresh water, saltwater, seawater, brine, or an aqueous salt solution. In the case ofbrines, the aqueous carrier fluid may comprise a monovalent brine or adivalent brine. Suitable monovalent brines may include, for example,sodium chloride brines, sodium bromide brines, potassium chloridebrines, potassium bromide brines, and the like. Suitable divalent brinescan include, for example, magnesium chloride brines, calcium chloridebrines, calcium bromide brines, and the like.

Additionally, the aqueous base fluids may be mixed with aqueous drillingmud. Water based drilling muds are known in the art, and any water baseddrilling mud may be used that does not interfere with the hydrophobic orsuperhydrophobic materials.

In certain embodiments, the water may be present in the cement or spacercomposition in an amount of from about 20% to about 95% by weight ofcement composition or by weight of spacer composition, from about 28% toabout 90% by wt. of cement composition, or from about 36% to about 80%by wt. of cement composition or spacer composition.

Cementitious Materials

A variety of cements can be used in the present invention, includingcements comprised of calcium, aluminum, silicon, oxygen, and/or sulfurwhich set and harden by reaction with water. Such hydraulic cementsinclude Portland cements, pozzolan cements, gypsum cements, high aluminacontent cements, slag cements, high magnesia content cements, shalecements, acid/base cements, fly ash cements, zeolite cement systems,kiln dust cement systems, microfine cements, metakaolin, pumice andtheir combinations. Portland cements that may be suited for use inembodiments of the present invention may be classified as Class A, C, Hand G cements according to American Petroleum Institute, APISpecification for Materials and Testing for Well Cements, APISpecification 10, Fifth Ed., Jul. 1, 1990. In addition, in someembodiments, hydraulic cements suitable for use in the present inventionmay be classified as ASTM Type I, II, or III. The cementitious materialsmay be combined with the aqueous base fluids to form a cement slurry.

Slurry Density

In certain embodiments, the cement compositions have a slurry densitywhich is pumpable for introduction down hole. In exemplary embodiments,the density of the cement composition in slurry form is from about 7pounds per gallon (ppg) to about 20 ppg, from about 8 ppg to about 18ppg, or from about 9 ppg to about 17 ppg.

Hydrophobic and Superhydrophobic Materials

Generally, the materials useful in the invention will be ones that arehydrophobic or superhydrophobic and absorb oil with very little to noabsorption of water. A hydrophobic surface is generally one that has awater contact angle (CA) greater than 90°. Superhydrophobic surfaces aregenerally those with a water CA greater than 150°. These materials,including their coatings or other properties that make them hydrophobicor superhydrophobic, should also have the strength to survive in cementthat is pumped into a wellbore during cementing operations. Commerciallyavailable sponges that have been modified and/or functionalized toinclude hydrophobic or superhydrophobic qualities, and those which haveinherent hydrophobic or superhydrophobic qualities, may be used.

Polymer substrates may include those made from polyacryonitrile (PAN),chitin, nanocellulose, polyurethane, carbon nanotubes and graphene, andcombinations thereof.

The surfaces of these polymers may be modified by coating (i.e.layering, vapor deposition, electroless deposition, electrochemicaldeposition, etc.) using hydrophobic polymers, superhydrophobic activatedcarbon, carbon nanotubes, graphene, alternating layers of differentsized particles (i.e. nanosilica and microsilica), metal containingcompounds or organometallic compounds.

Polyurethane sponges may be modified by utilizing electroless depositionof a film of copper, and then adding superhydrophobic coatings usingsolution-immersion processes. See Zhu, Q.; Pan, Q.; Liu, F., FacileRemoval and Collection of Oils from Water Surfaces throughSuperhydrophobic and Superoleophilic Sponges, J. Phys. Chem. C 2011,115, 17464-17470.

In addition to chemical modification of the surface, structuralmodifications can also induce or enhance hydrophobicity orsuperhydrophobicity. Some available structural modification methodsinclude anodic oxidation, etching, lithography, templating,electrospinning, solgel, and combinations thereof.

An exemplary material for use in this disclosure is that of a melaminesponge modified through silanization. The process involves immersing amelamine sponge in a solution of octadecyltrichlorosilane and tolune.Melamine sponges are basically a formaldehyde/melamine/sodium bisulfitecopolymer, and the silanization occurs through the covalent bonding ofalkylsilane compounds to the secondary amine groups on the sponge. Thisprocess is known in the art and demonstrated in Pham, V. H.; Dickerson,J. H., Superhydrophobic Silanized Melamine Sponges as High EfficiencyOil Absorbent Materials, ACS Appl. Mater. Interfaces, 2014. Thesefunctionalized superhydrophobic sponges may be able to absorb oil with acapacity of up to 163 times their weight.

The functionalized hydrophobic or functionalized superhydrophobicmaterial may be present in the amount of about 0.01% to about 25% byweight of the cementing composition. When used in a spacer fluid, thefunctionalized hydrophobic or functionalized superhydrophobic materialmay be present in the amount of about 0.01% to about 50% by weight ofthe spacer fluid.

Spacer Fluids

The disclosure is also directed to the use of a spacer fluid inpreparing a wellbore for cementation. Spacer fluids may be used toremove oil based muds that are present in the formation after drillingoperations or oil from the formation itself. The spacer fluid mayinclude at least one of a water based mud, an aqueous base fluid, andcombinations thereof. The spacer fluid also includes a functionalizedhydrophobic or functionalized superhydrophobic material as discussed inthe section above. The spacer fluid will immediately absorb oil as it isplaced in the wellbore. In an embodiment, the functionalized hydrophobicor functionalized superhydrophobic material is present in the amount ofabout 0.01% to about 50% by weight of the spacer fluid composition.

Cement Additives

The cement compositions of the invention may contain additives. Incertain embodiments, the additives comprise at least one of resins,latex, stabilizers, silica, pozzolans, microspheres, aqueoussuperabsorbers, viscosifying agents, suspending agents, dispersingagents, salts, accelerants, surfactants, retardants, defoamers,settling-prevention agents, weighting materials, fluid loss controlagents, elastomers, vitrified shale, gas migration control additives,formation conditioning agents, and combinations thereof.

Wellbore and Formation

Broadly, a zone refers to an interval of rock along a wellbore that isdifferentiated from surrounding rocks based on hydrocarbon content orother features, such as perforations or other fluid communication withthe wellbore, faults, or fractures. A treatment usually involvesintroducing a treatment fluid into a well. As used herein, a treatmentfluid is a fluid used in a treatment. Unless the context otherwiserequires, the word treatment in the term “treatment fluid” does notnecessarily imply any particular treatment or action by the fluid. If atreatment fluid is to be used in a relatively small volume, for exampleless than about 200 barrels, it is sometimes referred to in the art as aslug or pill. As used herein, a treatment zone refers to an interval ofrock along a wellbore into which a treatment fluid is directed to flowfrom the wellbore. Further, as used herein, into a treatment zone meansinto and through the wellhead and, additionally, through the wellboreand into the treatment zone.

As used herein, into a well means introduced at least into and throughthe wellhead. According to various techniques known in the art,equipment, tools, or well fluids can be directed from the wellhead intoany desired portion of the wellbore. Additionally, a well fluid can bedirected from a portion of the wellbore into the rock matrix of a zone.

As will be appreciated by those of ordinary skill in the art,embodiments of the cement compositions of the present invention may beused in a variety of subterranean applications, including primary andremedial cementing. For example, a cement slurry composition comprisingcement, a polymer, and water may be introduced into a subterraneanformation and allowed to set or cure therein. In certain embodiments,for example, the cement slurry composition may be introduced into aspace between a subterranean formation and a pipe string located in thesubterranean formation. Embodiments may further comprise running thepipe string into a wellbore penetrating the subterranean formation. Thecement slurry composition may be allowed to set or cure to form ahardened mass in the space between the subterranean formation and thepipe string. In addition, a cement composition may be used, for example,in squeeze-cementing operations or in the placement of cement plugs.Embodiments of the present invention further may comprise producing oneor more hydrocarbons (e.g., oil, gas, etc.) from a well bore penetratingthe subterranean formation.

The exemplary cement compositions disclosed herein may directly orindirectly affect one or more components or pieces of equipmentassociated with the preparation, delivery, recapture, recycling, reuse,and/or disposal of the disclosed cement compositions. For example, andwith reference to FIG. 2, the disclosed cement compositions may directlyor indirectly affect one or more components or pieces of equipmentassociated with an exemplary wellbore drilling assembly 100, accordingto one or more embodiments. It should be noted that while FIG. 2generally depicts a land-based drilling assembly, those skilled in theart will readily recognize that the principles described herein areequally applicable to subsea drilling operations that employ floating orsea-based platforms and rigs, without departing from the scope of thedisclosure.

As illustrated, the drilling assembly 100 may include a drillingplatform 102 that supports a derrick 104 having a traveling block 106for raising and lowering a drill string 108. The drill string 108 mayinclude, but is not limited to, drill pipe and coiled tubing, asgenerally known to those skilled in the art. A kelly 110 supports thedrill string 108 as it is lowered through a rotary table 112. A drillbit 114 is attached to the distal end of the drill string 108 and isdriven either by a downhole motor and/or via rotation of the drillstring 108 from the well surface. As the bit 114 rotates, it creates aborehole 116 that penetrates various subterranean formations 118.

A pump 120 (e.g., a mud pump) circulates drilling fluid 122 through afeed pipe 124 and to the kelly 110, which conveys the drilling fluid 122downhole through the interior of the drill string 108 and through one ormore orifices in the drill bit 114. The drilling fluid 122 is thencirculated back to the surface via an annulus 126 defined between thedrill string 108 and the walls of the borehole 116. At the surface, therecirculated or spent drilling fluid 122 exits the annulus 126 and maybe conveyed to one or more fluid processing unit(s) 128 via aninterconnecting flow line 130. After passing through the fluidprocessing unit(s) 128, a “cleaned” drilling fluid 122 is deposited intoa nearby retention pit 132 (i.e., a mud pit). While illustrated as beingarranged at the outlet of the wellbore 116 via the annulus 126, thoseskilled in the art will readily appreciate that the fluid processingunit(s) 128 may be arranged at any other location in the drillingassembly 100 to facilitate its proper function, without departing fromthe scope of the scope of the disclosure.

One or more of the disclosed cement compositions may be added to thedrilling fluid 122 via a mixing hopper 134 communicably coupled to orotherwise in fluid communication with the retention pit 132. The mixinghopper 134 may include, but is not limited to, mixers and related mixingequipment known to those skilled in the art. In other embodiments,however, the disclosed cement compositions may be added to the drillingfluid 122 at any other location in the drilling assembly 100. In atleast one embodiment, for example, there could be more than oneretention pit 132, such as multiple retention pits 132 in series.Moreover, the retention put 132 may be representative of one or morefluid storage facilities and/or units where the disclosed cementcompositions may be stored, reconditioned, and/or regulated until addedto the drilling fluid 122.

As mentioned above, the disclosed cement compositions may directly orindirectly affect the components and equipment of the drilling assembly100. For example, the disclosed cement compositions may directly orindirectly affect the fluid processing unit(s) 128 which may include,but is not limited to, one or more of a shaker (e.g., shale shaker), acentrifuge, a hydrocyclone, a separator (including magnetic andelectrical separators), a desilter, a desander, a separator, a filter(e.g., diatomaceous earth filters), a heat exchanger, any fluidreclamation equipment. The fluid processing unit(s) 128 may furtherinclude one or more sensors, gauges, pumps, compressors, and the likeused store, monitor, regulate, and/or recondition the exemplary cementcompositions.

The disclosed cement compositions may directly or indirectly affect thepump 120, which representatively includes any conduits, pipelines,trucks, tubulars, and/or pipes used to fluidically convey the cementcompositions downhole, any pumps, compressors, or motors (e.g., topsideor downhole) used to drive the cement compositions into motion, anyvalves or related joints used to regulate the pressure or flow rate ofthe cement compositions, and any sensors (i.e., pressure, temperature,flow rate, etc.), gauges, and/or combinations thereof, and the like. Thedisclosed cement compositions may also directly or indirectly affect themixing hopper 134 and the retention pit 132 and their assortedvariations.

The disclosed cement compositions may also directly or indirectly affectthe various downhole equipment and tools that may come into contact withthe cement compositions such as, but not limited to, the drill string108, any floats, drill collars, mud motors, downhole motors and/or pumpsassociated with the drill string 108, and any MWD/LWD tools and relatedtelemetry equipment, sensors or distributed sensors associated with thedrill string 108. The disclosed cement compositions may also directly orindirectly affect any downhole heat exchangers, valves and correspondingactuation devices, tool seals, packers and other wellbore isolationdevices or components, and the like associated with the wellbore 116.The disclosed cement compositions may also directly or indirectly affectthe drill bit 114, which may include, but is not limited to, roller conebits, PDC bits, natural diamond bits, any hole openers, reamers, coringbits, etc.

While not specifically illustrated herein, the disclosed cementcompositions may also directly or indirectly affect any transport ordelivery equipment used to convey the cement compositions to thedrilling assembly 100 such as, for example, any transport vessels,conduits, pipelines, trucks, tubulars, and/or pipes used to fluidicallymove the cement compositions from one location to another, any pumps,compressors, or motors used to drive the cement compositions intomotion, any valves or related joints used to regulate the pressure orflow rate of the cement compositions, and any sensors (i.e., pressureand temperature), gauges, and/or combinations thereof, and the like.

EXAMPLES

The invention having been generally described, the following examplesare given as particular embodiments of the invention and to demonstratethe practice and advantages hereof. It is understood that the examplesare given by way of illustration and are not intended to limit thespecification or the claims to follow in any manner.

Example 1

Sponge Water Absorption

Melamine sponges were obtained in a nonfunctionalized state and werefunctionalized to a superhydrophobic state by submersion in 5% wtoctadecyltrichlorosilane in toluene for 30 minutes. The functionalizedsponges were rinsed in toluene and dried at 120° F. for 1 hour. Thefunctionalized sponges were cut into small pieces to allow for easyintegration into a fluid system. Samples of non-functionalized andfunctionalized sponge were placed in room temperature water. FIG. 3Ashows that the functionalized material is not compatible with waterbecause it is floating on the surface, while the non-functionalizedmaterial readily absorbs water and sinks as seen in FIG. 3B.

Example 2

Sponges in Cement

An amount of 0.05% BWOC of the functionalized superhydrophobic material,as previously described on Sponge Water Absorption section, was added toa cement slurry composed of Class G cement and water mixed at 16.4 ppgdensity. The slurry-sponge mixture was placed in an atmosphericconsistometer with 0.5 g oil based fluid and conditioned at roomtemperature for 30 minutes. The conditioned slurry was then placed in anautoclave and heated to 160° F. over 30 minutes at 3000 psi. The slurrywas left to cure for 24 hours. The functionalized sponge has the abilityto absorb 100 times its weight in various organic solvents and oils. Asshown in FIGS. 4A,B, the addition of the functionalized sponge resultsin an even dispersion of the oil contamination, without compromising theslurry mixability and compressive strenght delevopment, by eliminatingthe formation of large oil pockets that can hinder the set of cement.The dark areas surrounding the sponge particles indicate preferentialabsorption of oil. FIG. 5 shows the ultrassonic compressive strength(UCS) of two slurries contaminated with oil-based mud (OBM), without andwith a funtionalized sponge, demonstrating the effect of thefunctionalized sponge. Improved results in compressive strengthdevelopment were observed by UCA with the addition of thesuperhydrophobic material in the presence of oil based drilling mud. Oneof skill in the art may realize that the use of superhydrophobicmaterial, as demonstrated in the data plotted in FIG. 5, but not limitedthereto, may be utilized in downhole operations such as wellborecementing, with the expectation of enhancing the resulting cement suchthat it may have improved compressive strength and fewer large oilpockets of contamination.

While preferred embodiments of the invention have been shown anddescribed, modifications thereof can be made by one skilled in the artwithout departing from the spirit and teachings of the invention. Theembodiments described herein are exemplary only, and are not intended tobe limiting. Many variations and modifications of the inventiondisclosed herein are possible and are within the scope of the invention.Use of the term “optionally” with respect to any element of a claim isintended to mean that the subject element is required, or alternatively,is not required. Both alternatives are intended to be within the scopeof the claim.

Embodiments disclosed herein include:

A: A method comprising: introducing a well cementing composition into awellbore, said cementing composition comprising: a pumpable slurry ofcement and at least one of a hydrophobic material, a superhydrophobicmaterial, and combinations thereof; and allowing at least a portion ofthe cementing composition to cure.

B: A composition for well cementing comprising: a pumpable slurry ofwellbore cement and at least one of a hydrophobic material, asuperhydrophobic material, and combinations.

C: A method of preparing a wellbore for cementation comprising:introducing a spacer fluid into a wellbore, said spacer fluidcomprising: at least one of a water based mud, an aqueous base fluid,and combinations thereof and at least one of a hydrophobic material, asuperhydrophobic material, and combinations thereof; and allowing thespacer fluid to absorb a portion of oil in the wellbore.

Each of embodiments A, B and C may have one or more of the followingadditional elements in any combination: Element 1: wherein the at leastone of hydrophobic material and superhydrophobic material is a polymermodified by at least one of coating, anionic oxidation, etching,lithography, templating, electrospinning, solgel, and combinationsthereof. Element 2: wherein the polymer comprises at least one ofpolyacryonitrile, chitin, nanocellulose, polyurethane, carbon nanotubesand graphene, and combinations thereof. Element 3: wherein the at leastone of hydrophobic material and superhydrophobic material comprises apolymer sponge. Element 4: wherein the sponge comprises melamine thathas been functionalized by silanization. Element 5: wherein thesilanization occurs through the covalent bonding of alkylsilanecompounds to the secondary amine groups on the sponge. Element 6:wherein the at least one of hydrophobic material and superhydrophobicmaterial is present in the amount of about 0.01% to about 25% by weightof the cementing composition. Element 7: further comprising allowing theat least one of hydrophobic material and superhydrophobic material toabsorb oil during the setting phase of the cement composition. Element8: further comprising at least one of a pump, a mixer, and combinationsthereof for combining the components of the cementing composition andintroducing the composition into the wellbore. Element 9: wherein the atleast one of hydrophobic material and superhydrophobic material ispresent in the amount of about 0.01% to about 50% by weight of thespacer fluid composition. Element 10: wherein at least a portion of theoil in the wellbore is from an oil based drilling mud. Element 11:further comprising introducing a cementing composition in to thewellbore after the spacer fluid has been introduced, wherein thecementing composition comprises a pumpable slurry of a wellbore cement.Element 12: wherein the cementing composition comprises at least one ofhydrophobic material, a superhydrophobic material, and combinationsthereof.

Numerous other modifications, equivalents, and alternatives, will becomeapparent to those skilled in the art once the above disclosure is fullyappreciated. It is intended that the following claims be interpreted toembrace all such modifications, equivalents, and alternatives whereapplicable.

What is claimed is:
 1. A method comprising: introducing a spacer fluidinto a wellbore, said spacer fluid comprising: at least one of a waterbased mud, an aqueous base fluid, and combinations thereof; and at leastone of hydrophobic material, a superhydrophobic material, andcombinations thereof; allowing the spacer fluid to absorb a portion ofoil in the wellbore; introducing a well cementing composition into awellbore, said cementing composition comprising: a pumpable slurry ofcement; and at least one of a hydrophobic material, a superhydrophobicmaterial, and combinations thereof, wherein the at least one ofhydrophobic material and superhydrophobic material is a polymer modifiedby at least one of coating, anionic oxidation, etching, lithography,templating, electrospinning, solgel, and combinations thereof, andwherein the at least one of hydrophobic material and superhydrophobicmaterial comprises a polymer sponge; and allowing at least a portion ofthe cementing composition to cure.
 2. The method of claim 1, wherein thepolymer comprises at least one of polyacryonitrile, chitin,nanocellulose, polyurethane, carbon nanotubes and graphene, andcombinations thereof.
 3. The method of claim 1, wherein the spongecomprises melamine that has been functionalized by silanization.
 4. Themethod of claim 3, wherein the silanization occurs through the covalentbonding of alkylsilane compounds to the secondary amine groups on thesponge.
 5. The method of claim 1, wherein the at least one ofhydrophobic material and superhydrophobic material is present in theamount of about 0.01% to about 25% by weight of the cementingcomposition.
 6. The method of claim 1, further comprising allowing theat least one of hydrophobic material and superhydrophobic material toabsorb oil during the setting phase of the cement composition.
 7. Themethod of claim 1, further comprising at least one of a pump, a mixer,and combinations thereof for combining the components of the cementingcomposition and introducing the composition into the wellbore.
 8. Amethod of preparing a wellbore for cementation comprising: introducing aspacer fluid into a wellbore, said spacer fluid comprising: at least oneof a water based mud, an aqueous base fluid, and combinations thereof;and at least one of hydrophobic material, a superhydrophobic material,and combinations thereof, wherein the at least one of hydrophobicmaterial and superhydrophobic material is a polymer modified by at leastone of coating, anionic oxidation, etching, lithography, templating,electrospinning, solgel, and combinations thereof, and wherein the atleast one of hydrophobic material and superhydrophobic materialcomprises a polymer sponge; and allowing the spacer fluid to absorb aportion of oil in the wellbore.
 9. The method of claim 8, wherein thepolymer comprises at least one of polyacryonitrile, chitin,nanocellulose, polyurethane, carbon nanotubes and graphene, andcombinations thereof.
 10. The method of claim 8, wherein the spongecomprises melamine that has been functionalized by silanization.
 11. Themethod of claim 10, wherein the silanization occurs through the covalentbonding of alkylsilane compounds to the secondary amine groups on thesponge.
 12. The method of claim 8, wherein the at least one ofhydrophobic material and superhydrophobic material is present in theamount of about 0.01% to about 50% by weight of the spacer fluidcomposition.
 13. The method of claim 8, wherein at least a portion ofthe oil in the wellbore is from an oil based drilling mud.
 14. Themethod of claim 8, further comprising introducing a cementingcomposition in to the wellbore after the spacer fluid has beenintroduced, wherein the cementing composition comprises a pumpableslurry of a wellbore cement.
 15. The method of claim 14, wherein thecementing composition comprises at least one of hydrophobic material, asuperhydrophobic material, and combinations thereof.